UNOFFICIAL TRANSLATION

------------------------------------------------------------------------------ UNOFFICIAL TRANSLATION IMPORTANT NOTE: In the event of discrepancy between the Greek and English version, the Greek text prevails --------------------------------------------------------------------------- GOVERNMENT OF GREECE GAZETTE B 3720/20 OCTOBER 2017 RAE DECISION Nr. 871/2017 (meeting of 18 October 2017) SECOND REVISION OF THE TARIFF REGULATION FOR THE BASIC ACTIVITIES OF THE NATIONAL NATURAL GAS SYSTEM (NNGS) according to para. 1 of article 88 of Law 4001/2011 and Law 4409/2016 THE REGULATORY AUTHORITY FOR ENERGY Taking into account: 1.. 35. Thought as follows: Because.. For the above reasons, decides: 1. The issue of the Revised Tariff Regulation with its Annex, with content as follows, which constitutes an integral part of the present decision 2. The notification of the present decision to the European Commission REGULATION FOR TARIFFICATION OF THE BASIC ACTIVITIES OF THE NNGS Page 1 of 46

TARIFF REGULATION FOR THE BASIC ACTIVITIES OF THE NATIONAL NATURAL GAS SYSTEM CHAPTER A GENERAL CLAUSES Article 1 Objective The Tariff Regulation of the Basic Activities 1 of the National Natural Gas System (Tariff Regulation) regulates the methodology for the determination of tariffs for the charge of of each Basic Activity according to the provisions of paragraph 2 of article 88 of Law 4001/2011/G.G /Α' 179/22.08.2011 (Law), and according to the provisions of article 61 of Law 4409/2016 (G.G Α' 136/28.07.2016) as amended by paragraph 12 of article 15 of the Law 4425/2016 (G.G Α' 185/30.09.2016). The present regulation does not regulate the methodology for the definition of tariffs for the Basic Activity of Gas Storage, for the cases where part of the National Natural Gas System is developed pursuant to case (δ) of paragraph 1 of article 67 of the Law, as well as for the case (ιζ) of paragraph 2 of article 68 of the Law. Article 2 Definitions 1. The terms mentioned in the Tariff Regulation have the content and the meaning attributed to them by Law 4001/2011, and the regulatory acts issued according to the authorizations of the referred Law. For the implementation of the Tariff Regulation the terms used herein shall have the following meaning: a.) Tariff Approval Decision: The decision of RAE, which approves the tariffs of each Basic Activity pursuant to the provisions of paragraph 5 of article 88 of the Law. 1 Translator s note: The Law uses the term Basic Activity for each main service offered by the System Operator (i.e. DESFA) to the users. Currently these are the high pressure transportation of gas (Basic Activity of Transmission) and the unloading, temporary storage and regasification of LNG (Basic Activity of LNG Facility); gas storage service is not provided. Page 2 of 46

b.) Tariff Recalculation Decision: The decision of RAE, which approves the recalculation of tariffs for each Basic Activity pursuant to the provisions of article 18 or 18A of the Regulation. c.) Short Term Application: Approved Application 2 for firm Transportation services or Approved Application for LNG Facility services or for interruptible services with duration less than three hundred and sixty five (365) continuous days. d.) Long Term Application: Approved Application for firm Transportation services or Approved Application for LNG Facility services with duration equal or greater than three hundred and sixty five (365) continuous days. e.) Interconnection Point: The point connecting the National Natural Gas System with another Transmission System, excluding the pipelines transmitting gas from an LNG Facility, a Storage Facility or a production facility of natural gas. f.) Transmission Tariff: The tariff for the use of the Transmission System. g.) LNG Tariff: The tariff for the use of the LNG Facility. h.) Marginal Price: The eligible minimum auction price for capacity booking within the transmission capacity auction defined as the sum of I. The product of the capacity charge coefficient (as defined in article 11) adjusted in proportion to the number of Days of the Year relevant to the standard capacity product for Delivery/ Reception 3 by the corresponding short-term multiplier for the use of the National Natural Gas System (NNGS) (as described in article 13) and II. In case of bundled product, the respective charge for the same Standard capacity product for Delivery/ Reception applicable to the use of the interconnected Natural Gas System i.) Settlement Auction Price: The price that will be paid by the Transmission User in order to acquire transmission capacity for Delivery/Reception via 2 Translator s note: According to the NNGS Administration Code, a User of the System signs a framework contract for the use of the Transmission System or the LNG Facility, and for each reservation of capacity submits an Application which is approved by the System Operator (Approved Application) 3 Translator s note: Gas delivery refers to the entry points and gas reception to the exit points of the Transmission System Page 3 of 46

the corresponding transmission capacity auction for the relevant standard capacity product for Delivery/ Reception, which is the sum of the Marginal Price at the time of the Transmission Capacity for Delivery / Reception usage and the Auction premium. j.) Reverse Flow: The Natural Gas flow direction opposite to the statistically prevailing flow at an interconnection point k.) Bi-Directional Flow: Either the statistically prevailing Natural Gas flow direction or the opposite direction. l.) Old Recoverable Difference is the Recoverable Difference of Years 2006-2015 plus the forecasted Recoverable Difference of Year 2016, as determined according to article 19[Β]. J.) As Weighted Average Tariff of NNGS for year n of the calculation period is considered the weighted tariff based on the Revenue for Capacity and Commodity for the sum of entries and exits of NNGTS, calculated as follows: where: period is the Weighted Average Tariff of NNGS for year ν of the calculation is the Required Revenue to be recovered of the basic activity of Transmission and of the basic activity of LNG Facility, as defined in Article 8A of present Tariff Regulation for each year (v) of the tariff calculation period as defined in par.3 of Article 11 of the present Tariff Regulation for year (v) of the tariff calculation period is the sum of maximum Daily Quantities of Natural Gas of all entries and exits of the NNGTS which are taken into consideration for the calculation of capacity tariff coefficients for year (v) of the tariff calculation period, according to Articles 9 and 11 par.3 of present Tariff Regulation is the number of days of year (v) of the tariff calculation period Page 4 of 46

is the sum of the yearly Quantities of Natural Gas of all entries and exits of NNGTS of year (v) of the tariff calculation period according to par.4 of Article 11 of present Tariff Regulation. The Weighted Average Tariff of NNGS of year (v) of the tariff calculation period is expressed either in /kwh/y GCV with the capacities ( and commodities ( expressed in kwh GCV respectively in the above formula or in /MWh/y GCV with the capacities ( and commodities ( expressed in MWh GCV respectively. Article 3 Principles and Periods for Calculation and Revision of Tariffs 1. The tariffs shall be determined according to the principle of recovery of the Required Revenue for each Basic Activity of the System Operator, in a way that the criteria of paragraph 2 of article 88 of the Law as well as those determined in Regulation (EC) 715/ 2009 (EE L 211/36) of the European Parliament and of the Council, of 13 July 2009, on conditions for access to the natural gas transmission networks and repealing Regulation (EC) 1775/2005, are fulfilled. 2. The tariff for each Basic Activity shall be calculated based on: a) The forecast for the evolution of the Required Revenue and the natural gas demand for the relevant Basic Activity for every Year of the Tariffs Calculation Period; as Tariff Calculation Period is defined the time period of four (4) consecutive Years. b) The actual data concerning the actual Required Revenue and the actual Revenue of the System Operator for the reference year of paragraph 3, in order to secure that no under- or over-recovery of Required Revenue occurs. 3. The tariffs shall be prepared by the System Operator during the year prior to the Tariff Calculation Period (Calculation Year), pursuant to the procedure of article [19]. The forecasts in relation to the evolution of the Required Revenue and the natural gas demand of each Basic Activity shall be prepared by the System Operator taking into consideration the relevant actual data of the Year prior of the Calculation Year (Reference Year) and the reasonable estimates of the System Operator in relation to the evolution of the aforementioned data during the Tariff Calculation Period, pursuant to the provisions of article [19]. Page 5 of 46

4. Regular Tariff Revision is conducted within the fourth (4th) Year of each Tariff Calculation Period, which is set as Calculation Year for the following Calculation Period. The Regular Tariff Revision shall be conducted according to the procedure of article [19]. Especially for the first implementation of this regulation, regular tariff revision will be carried out during 2018 which becomes Calculation Year for the following Calculation Period. 5. Extraordinary Tariff Revision shall be conducted under the conditions and pursuant to the procedure of article [20]. 6. Recalculation of Tariff coefficients for Transmission and LNG Facility for each year of the calculation period, will be carried out during the previous year according to article [18]. 7. Extraordinary Recalculation of transmission and LNG tariff coefficients that will be in force during each Year of the Tariff Calculation Period is conducted during the previous year according to article [18A]. CHAPTER B REQUIRED REVENUE Article 3A Required Revenue 1. The Required Revenue for each year (v), shall be calculated for each Basic Activity on a Yearly basis and in nominal values as the sum of: a) The Return on the Regulated Asset Base of the relevant Basic Activity at the end of year (v), as defined in articles [4] and [6]. b) The Regulated Depreciation of assets of the relevant Basic Activity for the year (v) as defined in article [7]. c) The Regulated Operating Expenses of the relevant Basic Activity for the year (v) as defined in article [7Α]. All the above mentioned calculations are made in accordance with the IFRS standards. Page 6 of 46

2. The Required Revenue of the NNGS for a certain Year is equal to the sum of Required Revenue for each Basic Activity at the said Year. 3. The Required Revenue for the basic activity of Transmission as well as for the basic activity of LNG Facility is further allocated to every Entries and Exits of the transmission system according to articles [8] and [10]. 4. The Required Revenue of each Basic Activity is defined arithmetically for each Year of the Tariff Calculation Period by the Tariff Approval Decision during the Tariff Revision. Article 4 Regulated Asset Base (RAB) 1. Regulated Asset Base (RAB) of a Basic Activity for the year (v) is the capital employed for the Basic Activity by the System Operator at the end of the year (v). 2. The RAB of a Basic Activity is calculated for each year (v) as the sum of: a) The Regulated Undepreciated Value of existing tangible and intangible assets of the relevant Basic Activity at the end of the year (v) according to paragraph 3. b) The percentage KK (%) of the working capital for the Basic Activity for the year (v) as calculated according to paragraph 5. The working capital for Transmission and LNG Facility is the difference between Current Assets and Current Liabilities as they are presented in the published financial statements of the System Operator, or, per Basic Activity, according to the implementation of the Accounting Unbundling Rules. In any case the working capital cannot exceed the cash safety deposit as this is defined in par. 6, increased by the percentage of 33% and allocated to the Basic Activity of Transportation and LNG Facility proportionally to the Regulated Undepreciated Value of assets of each Basic Activity, as this is defined in point (a) above. 3. The Regulated Undepreciated Value of assets for each Basic Activity at the end of the year (v) is calculated, when from the regulated acquisition value of fixed assets for every Basic Activity at the end of the year (v), as defined in article 4, the following items are excluded: a.) The depreciation of fixed assets corresponding to the Regulated acquisition value. Page 7 of 46

b.) The unamortized grants that have been included in the share capital at the end of the calculation year, calculated based on the data presented on table 13 of RAE Decision 722/202 (G.G B 2385/27.08.2012) considering that the annual depreciation after the year 2010, is equal to the depreciation of year 2010, i.e. 7.114.759 / year. These grants are allocated between the Transmission Basic Activity and the LNG Facility Basic Activity by seventy two (72%) and twentyeight (28%) percent respectively. 4. Subject to paragraph 6, the Regulated Acquisition Value of fixed assets for each Basic Activity at the end of the year (v) is calculated as the acquisition value of fixed assets including assets under construction, minus the following items: a.) The own-produced assets not corresponding to materials. b.) The connection fees and additional connection fees, as calculated in article [5] and [5A]. c.) The capitalized interest during construction period with the exception of that corresponding to projects under construction according to RAE Decision 594/2012 (G.G 2093/5.7.2012) which were classified as Major Projects. These projects are included in the RAB on 31.12.2016. d.) Grants for fixed Assets recorded in the Financial Statements of the System Operator. 5. The percentage KK (%) of the working capital for each Tariff Calculation Period is defined with the Tariff Approval Decision at any ordinary or extraordinary Tariff review. The percentage KK (%) takes a value proportionally between 50% to 100% according to the level of the current ratio for the Transmission Basic Activity and the LNG Facility Basic Activity. The percentage KK (%) receives value: a.) 100% if the current ratio is less than 1.5 b.) 51%-99% if the current ratio is between 1.5-2 (with linear configuration) and c.) 50% if the current ratio is greater than 2. Page 8 of 46

In case of negative working capital, the percentage (%) is set equal to zero (0). The Current Ratio is defined as the ratio Current Assets / Current Liabilities. Each month, the System Operator is obliged to retain enough cash to cover at least the budgeted liabilities of the next 4 months. 6. The Operator is obliged to maintain a cash safety deposit equal to twenty percent (20%) of the forecasted yearly operating expenses for the Basic Activity of Transportation and the Basic Activity of LNG including debt and tax payment obligations. In addition, the Operator must maintain any cash reserves required to meet all its planned obligations in accordance with its cash flow budget as well as cash reserves for the availability of Users financial guarantees and the security of supply account. 7. For the implementation of paragraph 1(a) of article [19A], new projects, completed or under construction, are included in the RAB of the relevant Basic Activity, after the approval of the National Natural Gas System Development Plan or after the publication of the Small Projects List in which they are included. 8. Any revaluation of Assets of the System Operator after the initial recording in the Financial Statements will not be taken into account in the RAB of the corresponding Basic Activity. 9. The distribution of the fixed assets to each Basic Activity is carried out in accordance to the accounting unbundling rules approved by RAE, as per paragraph 4 of article 89 of the Law. 10. The Regulated Asset Base (RAB) is defined arithmetically for each year of the Tariff Calculation Period with the Tariff Approval Decision at any ordinary or extraordinary revision. The same Decision defines the projects that have been included in the forecasted RAB for which disbursements are foreseen within the Tariff Calculation Period and their remaining budget. Article 5 Definition of Connection Fee 1. In case of a User s Connection Project with the Transmission System, which includes the connection of a Reception Facility or a Connected Gas System, the User who applied for the Connection Project and whose request was approved by the System Operator pursuant to the provisions of the National Page 9 of 46

Natural Gas System (NNGS) Administration Code, shall pay the Connection Fee to the System Operator. The Connection Fee is calculated as the sum of: a) The actual construction cost of the relevant metering or metering and regulating station for the Natural Gas reception installation, including the cost of telecommunication equipment, up to the limit of three (3) million Euro in 2017 nominal values per metering or metering and regulating station, and b) The actual cost of the pipeline upstream of the new Exit Point which is created and up to the limit of two (2) kilometers, including the necessary equipment for the operation of the pipeline, up to the limit of two (2) million Euros in 2017 in nominal values. In case that the length of the pipeline upstream of the new Exit Point exceeds two (2) kilometers, the part of the total actual cost of the upstream pipeline included in the Connection Fee is calculated proportionally with the ratio of the part of the pipeline with a length equal to two (2) kilometers to the total length of the upstream pipeline and up to the limit of two (2) million Euros in 2017 in nominal values. 2. The aforementioned monetary limits are adjusted every Year according to the change in the average annual Consumer Price Index (%) of the previous year, as published by the Hellenic Statistical Authority. In case of negative index, the monetary limits will not be adjusted. 3. In respect to the calculation of the cost under cases a) and b) of paragraph [1], the cost of own-produced assets shall not be included, while the cost of interest during construction period corresponding to the connection project shall be included. 4. In case the Connection Project is related to more than one Transmission User, the Connection Fee for each Transmission User is calculated according to the methodology described in paragraph [1], where the amounts of cases a) and b) are allocated among the Transmission Users in proportion to the Transmission Capacity that they have applied for the relevant Connection Project. 5. The part of the cost of the Transmission User s Connection Project, that reflects the amount that is paid by the applicant Transmission User as Connection Fee, is not included in the RAB of the NNGS and its depreciation is not recovered. Page 10 of 46

6. New investments that are required after the beginning of operation of a Connection Project due to damage or necessary equipment upgrade, are realized by the System Operator and are included in the RAB of the NNGS according to paragraph 7 of article [4]. 7. In case a reception facility is fed by the transmission system without a relevant metering or metering and regulating station of the National Natural Gas System, the System Operator implements the relevant investment and the Transmission User bears the Connection Fee according to the present article, unless within a period of ninety (90) days after relevant notification by the System Operator, which takes place before the start of the engineering design of the project, the Transmission User notifies the System Operator requesting the disconnection of his installation from the National Natural Gas System. For the purpose of this provision, as reception facility is meant the totality of installations belonging to the same physical or legal person within the geographical boundaries of the installation. Article 5Α Criterion for the Financial Feasibility of a New Project 1. For the financial feasibility of a new Connection Project, pursuant to the provisions of the NNGS Administration Code, the System Operator shall estimate the impact that the implementation of the new Project will have on the Weighted Average Tariff for the Use of the NNGS for a period of Twenty (20) Years (Average Tariff Period). 2. The Weighted Average Tariff for the Use of the NNGS during the Weighted Average Tariff Period is calculated according to the mathematic formula of paragraph J of article [2] of present Tariff Regulation, discounted to the first Year of the Weighted Average Tariff Period. 3. For the calculation of the net present value of the values referred in the previous paragraph, the Weighted Average Cost of Capital in force is used as discount rate. 4. For the calculation of the impact on the Weighted Average Tariff for the Use of NNGS are taken into consideration the budgeted cost of implementation of a new Connection Project, excluding grants, Connection Fee, capitalized construction period interest and own-produced assets not corresponding to materials, the budgeted Operating Expenses which result from the Page 11 of 46

implementation of the new project, as well as the additional Transmission Capacity and Commodity of Natural Gas which are estimated to be transmitted in the NNGS due to the implementation of the new project. 5. In case the integration in the RAB of the new project does not cause an increase in the Weighted Average Tariff for the Use of the NNGS during the Weighted Average Tariff Period, the project is considered as cost-efficient. 6. In case the integration in the RAB of the new project causes an increase tin the Weighted Average Tariff for the Use of the NNGS during the Weighted Average Tariff Period, the portion of the total cost of the new project that causes the increase of the Average Tariff is calculated. 7. The calculated portion of the total cost that causes the increase of the Average Tariff may be paid by the Transmission User who requested the connection project as an Additional Connection Fee in order for his request to be accepted by the System Operator according to the provisions of the NNGS Administration Code and the specific provisions of the Connection Agreement. The additional connection fee mentioned is not included in the RAB and relevant depreciation is not recovered. 8. In case the connection project is requested by more than one Transmission Users, the Additional Connection Fee, mentioned above, will be allocated to each Transmission User according to the Transmission Capacity each Transmission User has requested for the relevant connection project. 9. The System Operator, for the evaluation of the impact of the implementation of a Development Project 4 on the tariff for use of the NNGS, pursuant to the provisions of the NNGS Administration Code, may apply the provisions of this article. Article 6 Return on the Regulated Asset Base (RAB) 1. As Return on the RAB is defined the return that is reasonably expected to be received by an investor on a long term basis from alternative investments of equivalent risk and is calculated by multiplying the RAB with the Weighted Average Cost of Capital of the System Operator. 4 Translator s note: Two kinds of projects are foreseen in the NNGS Administration Code: Connection projects, which are requested by Users and are not allowed to cause an increase in the average tariff as defined in the Tariff Regulation, and Development projects, which are proposed by DESFA. Page 12 of 46

2. The Return on the RAB is calculated per Year 3. The Weighted Average Cost of Capital is calculated in nominal pre-tax values according to the following formula: WACC Where: pre tax, nominal ROE post tax, (1 G) (1 TX) nominal G DR WACC pre-tax, nominal (Weighted Average Cost of Capital pre-tax nominal): The Weighted Average Cost of Capital pre-tax in nominal values. G (Gearing Ratio): The average of the Annual Gearing Ratios concerning Basic Transmission Activity and LNG Activity during the Tariff Calculation Period estimated using data from the Reference Year and in accordance with the most recent business plan of the System Operator. The Annual Gearing Ratio is defined as the ratio of the sum of the total debt (D) concerning Basic Transmission Activity and LNG Activity of a Year divided by the sum of the total debt (D) plus the total equity (E) concerning Basic Transmission Activity and LNG Activity. RAE may justifiably set an average gearing ratio (G) during the Tariff Calculation Period in the case that the estimated capital structure of the System Operator as per the latest Business Plan, is not optimal from the regulatory point of view. In any case the actual Average Gearing Ratio cannot exceed the value of zero point five (0,5). The value included in the Tariff Approval Decision is not subject to the limitation of the actual capital structure of the System Operator. ROE post-tax, nominal (Return on Equity post-tax, nominal): The projected return on System Operator s equity in nominal post-tax values, which is calculated according to paragraph [4]. DR (Debt Rate): The projected Debt Rate is the average of the annual Debt Rates during the Tariff Calculation Period, according to the most recent business plan of the System Operator. TX (Tax Rate): The estimated average rate of annual profit taxation of the System Operator, during the Tariff Calculation Period. 4. The expected return on System Operator s equity in nominal post tax values is calculated according to the following formula: Page 13 of 46

ROE post tax, nominal RFR CRP β MRP Where: RFR (Risk Free Rate): The return of an investment without risk which is defined based on the average yield of a ten-year government bond in the twelve months until the last working day of the month (v-2) [where v is the month of the required submission of the required revenue] of the Eurozone Country with the highest Credit Rating by all three major credit rating agencies (Standard & Poor's (S & P), Moody's and Fitch Group). If two or more countries have the same score, the country with the lowest yield in the last twelve (12) months is selected. CRP (Country Risk Premium): Investment risk rate in Greece. This figure is added to the return on investment without risk and is determined taking into account the economic conditions of investing in a monopolistic activity in Greece, in particular: a) The investment plan of the System Operator, especially the amount of new funds required to implement it and b) The margin between the average yield of a ten-year Greek government bond and the ten-year government bond that is used as the basis for calculating the return on investment without risk (Risk Free Rate) during the same period. This premium cannot be greater than four percent (4%). MRP (Market Risk Premium): The market risk premium, which is defined based on historical data and estimates on the evolution of returns of stock versus government bonds, in the largest possible sample of developed countries. To determine this parameter, information may be obtained from relevant reports of accredited financial institutions, universities, and from relevant international literature. β (Beta factor): Factor of systematic risk of System Operator s own equity, which is based on Blume systematic equity risk factors, for the last five years (5) up to the reference year, for stock exchange listed Transmission and Distribution Gas Network Operators acting without competition in the European Union. 5. The calculation of Weighted Average Cost of Capital of the System Operator in nominal post tax values, in real post tax and in real pre-tax values is based on the following formulas: Page 14 of 46

WACC post tax, nominal WACC pre tax, nominal (1 TX) WACC post tax, real WACC post tax, nominal (1 Inf) Inf WACC pre tax, real WACC post 1 TX tax, real Where: WACC post-tax, nominal: (Weighted Average Cost of Capital post-tax nominal): The Weighted Average Cost of Capital of the System Operator in nominal post tax values. WACC pre-tax, nominal: (Weighted Average Cost of Capital pre-tax nominal): The Weighted Average Cost of Capital of the System Operator in nominal pre-tax values, as calculated according to paragraph [3]. TX (Tax Rate): The projected rate of total profit taxation of the System Operator, as calculated according to paragraph [3]. WACC post-tax, real: (Weighted Average Cost of Capital post-tax real): The Weighted Average Cost of Capital of the System Operator in real post tax values. Inf: The average of the projected annual average inflation rate of each Year of the Tariff Calculation Period. WACC pre-tax, real: (Weighted Average Cost of Capital pre-tax real): The Weighted Average Cost of Capital of the System Operator in real pre-tax values. 6. The Weighted Average Cost of Capital may differ per Year of the Tariff Calculation Period, per Basic Activity and per new project category. 7. The Weighted Average Cost of Capital as well as the parameters for its calculation, according to the provisions of this article, is defined arithmetically with the Tariff Approval Decision at any ordinary or extraordinary Tariff Revision. Page 15 of 46

Article 7 Regulated Depreciation of Fixed Assets 1. The Depreciation of fixed assets of each Basic Activity for every year of the Tariff Calculation Period, included in the Required Revenue (Regulated Asset Depreciation), is the Depreciation for the said year of the Regulated Acquisition Value minus the amortization for the corresponding year of grants that have been included in the share capital of the System Operator in accordance with paragraph 3 (b) of article [4]. 2. Any revaluation of Assets of the System Operator after the initial recording in the Financial Statements will not be not taken into consideration in the calculation of the Fixed Assets Depreciation. 3. The Regulated Depreciation of Fixed Assets of each Basic Activity is defined arithmetically for each year of the Tariff Calculation Period in the Tariff Approval Decision at any ordinary or extraordinary Tariff Review. Article 7Α Regulated Operating Expenses 1. The operating expenses of each Basic Activity for every year of the Tariff Calculation Period which are included in the Required Revenue (Regulated Operating Expenses), are the reasonable expenses of the System Operator for the operation and maintenance of the NNGS in an efficient, cost-effective and reliable way. 2. For the estimation of Regulated Operating Expenses for every Year of the Tariff Calculation Period, the following shall be taken into consideration: a) The operating expenses data extracted from the System Operator s financial statements of the Reference Year. The allocation of total operating expenses of System Operator to each Basic Activity is conducted according to the accounting unbundling rules, which are approved by RAE, pursuant to the provisions of paragraph 4 of article 89 of the Law. b) Indexes for adjustment of the operating expenses per expense category in nominal values, submitted by the System Operator according to the procedure of article [19]. Page 16 of 46

c) Any other element that may affect the configuration of operating expenses for the following Years of the Tariffs Calculation Period, which is submitted by the System Operator, pursuant to the procedure of article [19]. d) The need for continuous improvement of the effectiveness of the System Operator and of the quality of the provided services. 3. The Regulated Operating Expenses shall not include: a) Expenses reimbursed by the Transmission Users separately, in accordance with the provisions of the NNGS Administration Code, as for offsetting the System Operator s costs for supplying balancing gas and operational gas and for security of supply compensations according to RAE Decision 344/2014 (G.G B 2536 / 23.09.2014). b) System Operator s financial costs c) Operating costs grants d) Fines imposed on the System Operator by administrative authorities. e) Cost provisions. Cost provisions are taken into account the Year they are realized. 4. The Regulated Operating Expenses include: a) Reasonable costs for the study and evaluation of investments that ultimately did not materialize. b) The own-produced assets not corresponding to materials. c) Reasonable System Operator costs for capacity reservation in the NNGS or any other Natural Gas System, that are not compensated in any other way. 5. The Regulated Operating Expenses of the System Operator include the reasonable and proportional expenses for his participation to the activities of the European Network of Transmission System Operators for Gas. 6. The Regulated Operating Expenses for the Basic Activity of LNG Facility of each Year as mentioned in paragraphs 3 and 4, result after the deduction of income from the sale of electricity from the System Operator to the Page 17 of 46

Independent Power Transmission System Operator, pursuant to the provisions of paragraph 4 of article 68 of the Law, as in force, and to any other relevant provisions. 7. The forecasted Regulated Operating Expenses of each Basic Activity are defined arithmetically for each Year of the Tariff Calculation Period with the Tariff Approval Decision at any ordinary or extraordinary Tariff Revision. Article 8 Dispersion of Required Revenue of the Basic Activity of LNG Facility 1. Pursuant to the provision of paragraph 3 of Article 88 of the Law, a percentage of the Required Revenue of the Basic Activity of LNG Facility (LNG Facility Dispersion Percentage: SocLNG) may be added to the Required Revenue of the Basic Activity of Transmission and be recovered through the Transmission Tariff. 2. The LNG Facility Dispersion Percentage is defined arithmetically with the Tariff Approval Decision at any ordinary or extraordinary Tariff Revision. Article 8Α Required Revenue to be Recovered 1. The Required Revenue To Be Recovered for the Basic Activity of Transmission in the year (v) of the Tariff Calculation Period is calculated as the sum of: a) The Required Revenue for the Basic Activity of Transmission of the said year (v) of the Tariff Calculation Period. b) The Recoverable Difference corresponding to the Basic Transmission Activity at the end of Year (v-2) multiplied by the factor (1 + inf), where inf is the average Consumer Price Index of the Year (v-2), where in case of negative value inf is considered equal to zero, as defined according to article [19A]. c) In case article 18A is applied during year (ν-1), the forecasted Recoverable Difference at the end of Year (ν-1), as calculated according to article [19A]. Page 18 of 46

d) The Old Recoverable Difference which is recovered in year (v) and is allocated to the Basic Activity of Transmission, as determined in accordance with Article [19B]. e) The product of SocLNG percentage by the sum defined in paragraph 2 of this article. 2. The Required Revenue to be Recovered for the Basic Activity of LNG Facility in Year (v) of the Tariff Calculation Period, is calculated as the product of the percentage (1 - SocLNG) multiplied by the sum of: a) The Required Revenue for the Basic Activity of LNG Facility for the corresponding year (v) of the Tariff Calculation Period. b) The Recoverable Difference corresponding to the Basic Activity of LNG Facility at the end of Year (v-2), multiplied by the factor (1 + inf) where inf is the average Consumer Price Index of Year (v-2), where in case of negative value inf is considered equal to zero, as defined according to article [19A]. c) In case article 18A is applied during year (ν-1), the forecasted Recoverable Difference at the end of Year (ν-1), as calculated according to article [19A]. d) The Old Recoverable Difference which is recovered in year (v) and is allocated to the Basic Activity of Transmission, as determined in accordance with Article [19B]. 3. In the Tariff Approval Decision at any ordinary or extraordinary Tariff Review, the Required Revenue to be Recovered for each Basic Activity is defined for the first year of the Tariff Calculation Period. In the Tariff Recalculation Decision issued in accordance with articles [18] and [18A], the Required Revenue to be Recovered in the year relevant to the Tariff Recalculation Decision, is defined. CHAPTER C DETERMINATION OF TARIFFS Article 9 Entries and Exits of the Transmission System Page 19 of 46

1. The tariff coefficients for the use of the Transmission System are defined separately for each one of the Entry and Exit of the Transmission System. 2. The User of the Transmission System is charged separately for the use of each Entry Point to which gas is delivered and for use of the Exit Point from which gas is received, pursuant to the provisions of the NNGS Administration Code and the Approved Application concluded with the System Operator, according to the Entry or Exit to which said Entry or Exit Point belongs respectively. The charge for the use of an Exit Point shall not be allowed to differ according to the Entry Point to which the gas, which is received from said Exit Point, is delivered. 3. In case that, pursuant to the NNGS Administration Code, the Transmission User is allowed to submit an application exclusively for the reservation of Transmission Capacity for Delivery with delivery of Natural Gas to one or more Entry Points, or for the reservation of Transmission Capacity for Reception with reception of Natural Gas from one or more Exit Points, especially in the case of operation of a Virtual Gas Delivery/Reception Point, the Transmission User shall be charged only for the use of the Entry or Exit Points, respectively, which are included in the relevant Approved application. 4. For the determination of the Transmission Tariffs for each Entry and Exit of the Transmission System: a) The Required Revenue to be recovered corresponding to the Basic Activity of Transmission is allocated to each Entry and Exit of the Transmission System, pursuant to Article [10]. b) The forecasted maximum Daily and Annual Quantity of Natural Gas for each Year of the Tariff Calculation Period, are determined separately for each Entry and Exit of the Transmission System. Especially as far as Exits are concerned, the maximum Daily Quantity received from a specific Exit per annum is defined as the sum of maximum Daily Quantities of Natural Gas received from each Exit Point of said Exit, irrespective of the Day of the Year in which said Quantities are expected to be received. 5. The Entries and Exits of the Transmission System are determined as follows: a) Entry «Sidirokastro»: the part of the Transmission System from the Import Point of Natural Gas at the Greek-Bulgarian border to the natural gas valve station Karperi of the prefecture of Serres, the latter not included. Page 20 of 46

b) Entry Kipi : the part of the Transmission System from the Import Point of Natural Gas at the Greek-Turkish border to the entrance of the valve station at the metering station "Alexandroupoli" of the prefecture of Evros, the latter not included. c) Entry Agia Triada : the part of the Transmission System which includes two offshore pipelines between the LNG Station on the island of Revythoussa and the metering station Agia Triada of the prefecture of Attica, the corresponding metering station Agia Triada and the pipeline from the metering station Agia Triada to the valve station "Megara" of the prefecture of Attica, the latter not included. d) Exit "North East Zone": the part of the Transmission System from the entrance of the valve station at the metering station "Alexandroupoli" of the prefecture of Evros to the valve station "Komotini" of the prefecture of Rodopi, the latter not included. e) Exit North Zone : the part of the Transmission System from the valve station "Komotini" of the prefecture of Rodopi and from the natural gas valve station "Karperi" of the prefecture of Serres to the exit of the valve station at the Centre of Operation and Maintenance in Nea Mesimvria of the prefecture of Thessaloniki, excluding the compressor station in Nea Mesimvria. f) Exit South Zone : the part of the Transmission System from the exit of the valve station at the Center for Operation and Maintenance in Nea Messimvria of the prefecture of Thessaloniki and southern, including the Compression Station in Nea Messimvria and excluding the Entry Agia Triada. 6. All interconnection points with other Transmission Systems are considered as Entry Points for the purposes of this Regulation. The use as an Exit Point of an Entry Point which is also an Interconnection Point, and vice versa, is charged with the coefficients of the respective Entry as calculated in accordance with Article [11]. 7. The definition of Entries and Exits can be modified by the Tariff Approval Decision at any Ordinary or Extraordinary Tariff Revision, or by the Tariff Recalculation Decision at every annual Tariff Recalculation or at the creation of a new Entry Point in the NNGS as defined in paragraph 3 of Article [10] of this Regulation. Page 21 of 46

8. By the Tariff Approval Decision at any ordinary or extraordinary Tariff Review, the forecasts of Maximum Daily and Annual Quantity of Natural Gas are defined in accordance with paragraph 4 (b) above for the first year of the Tariff Calculation Period. By the Tariff Recalculation Decision in accordance with Article [18], the forecasts of Maximum Daily and Annual Quantity of Natural Gas in accordance with paragraph 4 (b) above are defined for the year relevant to the Tariff Recalculation Decision. Article 10 Allocation of the Required Revenue to be Recovered from the Basic Activity of Transmission to the Entries and Exits of the Transmission System 1. The Required Revenue to be Recovered of the Basic Transmission Activity as defined in paragraph 1, article [8A] is allocated to the Entries and to the Exits of the Transmission System. The relevant percentages are defined in the Tariff Decision and can be revised at any Ordinary or Extraordinary Tariff Revision. 2. Further allocation of the Required Revenue to be Recovered allocated to the Entries to each Entry, is made so that the capacity and commodity charge coefficients for the use of each Entry, including the charge for the use of the LNG facility for the case of the Entry "Agia Triada", do not significantly differ. The percentages of further allocation resulted as above, are defined in the Tariff Approval Decision at any Ordinary or Extraordinary Tariff Revision and may be reviewed at any Tariff Recalculation, as well as in accordance with paragraph 3 of this Article. 3. In the case of a new Entry Point for which no tariff has yet been defined, the System Operator notifies RAE at least six months (6) prior to the projected operational date of the Entry Point according to the Development Plan. Simultaneously the System Operator submits a proposal to RAE for approval, redefining the allocation percentages referred to in paragraph 2 and the resulting new coefficients for the use of each Entry, keeping unchanged all other calculation parameters. After approval by RAE, the System Operator shall publish on its website the new tariffs for the use of Entries, which become effective upon the date of start of operation of the new Entry Point, the latter being published in the System Operator s webpage. 4. Further allocation of the Required Revenue to be Recovered by the Exits to each Exit as defined in article [9], is made taking into consideration the adjusted acquisition value of fixed assets of each Exit. The latter is calculated Page 22 of 46

as the acquisition value of the assets of the Exit with the following adjustments: a) In the case of North East Exit Zone, the acquisition value of fixed assets of the Exit is decreased by a percentage equal to the product of (aa) the ratio of the acquisition value of fixed assets used for transmission of gas to other Exits as well to the total assets acquisition value and (bb) the ratio of transmitted annual gas quantity that continues towards other Exits to the total gas exiting the North East Exit Zone. b) In the case of North Exit Zone, the acquisition value of fixed assets of the Exit is increased by the decrease of the acquisition value of Northeastern Exit calculated in paragraph (a) above, and then the new calculated amount is decreased by a percentage equal to the product of (aa) the ratio of the acquisition value of fixed assets that are used for transmission of gas to other Exits and (bb) the ratio of transmitted annual gas quantity that continues towards other Exits to the total gas exiting the North Exit Zone. c) In the case of the South Exit Zone, the acquisition value is increased by the decrease of acquisition value of North Exit calculated in paragraph (b) above. 5. The percentages that allocate the Required Revenue to be Recovered by the Exits to each Exit according to the previous paragraph, are calculated for the year (v) with the data of the year (v-2) and defined in the relevant Tariff Approval or Tariff Recalculation Decision. Article 11 Calculation of the Tariff coefficients 1. The Transmission Tariff includes: a) Charge in proportion to the Transmission Capacity of Delivery or Reception that is booked by the Transmission User at an Entry or Exit, correspondingly, pursuant to the provisions of the NNGS Administration Code and the Approved Transmission Application concluded with the System Operator, and b) Charge in proportion to the Quantity of Natural Gas that is delivered by the Transmission User to an Entry or is received by him at an Exit of the Page 23 of 46

Transmission System, pursuant to the provisions of the Approved Transmission Application concluded with the System Operator. 2. For the application of the annual Transmission Tariff, the coefficient of charge for reserved Transmission Capacity (ΣΔΜ i) and the coefficient of charge for Transmission Quantity (ΣΕΜ i) are determined separately for each Entry and Exit (i) of the System and for each corresponding year. 3. The coefficient of charge for reserved Transmission Capacity (ΣΔΜ i) [in /(kwh G.C.V./day)/year] is calculated according to the following formula: ΣΔΜ i = TRACaP x RR TRA,i / (CAP TRA,i x β ΤΡΑ,ι) Where: TRACap: Regulated percentage (%), which receives a value from zero (0%) to a hundred (100%) percent and is determined by the Tariff Approval Decision at any Ordinary or Extraordinary Tariff Revision. RR TRA, i: The Required Revenue to be Recovered from the Entry or Exit (i) during the corresponding year. CAP TRA, i: The sum of maximum Daily Quantities of Natural Gas delivered to each Entry Point of Entry (i) or received by each Exit Point of Exit (i), respectively, during the corresponding year. In case of bi-directional gas flow to an Entry Point which is an interconnection point, the sum of projected maximum Daily Quantities to both directions is taken into account. β TRA, i: Short-term contracts facilitating factor for the Entry or Exit (i) of the transmission system as defined in paragraph 10. 4. The coefficient of charge for Transmission Quantity of Natural Gas (ΣΕΜ i) [in /(kwh G.C.V.)] shall be calculated according to the following formula: ΣΕΜ i = (1-TRACap) x RR TRA,i / COM TRA,i Where: COM TRA, i: The sum of Quantities of Natural Gas delivered to each Entry Point Page 24 of 46

of Entry (i) or received by each Exit Point of Exit (i), respectively, during the corresponding year. In case of bi-directional gas flow to an Entry Point which is an interconnection point, the sum of projected annual Quantities to both directions is taken into account. 5. The LNG Tariff includes: a) Charge in proportion to the Regasification Capacity reserved by an LNG User, pursuant to the provisions of the NNGS Administration Code and the Approved Transmission Application concluded with the System Operator, and b) Charge in proportion to the Quantity of LNG that is regasified on behalf of an LNG User, pursuant to the provisions of the NNGS Administration Code and the Approved Transmission Application concluded with the System Operator. 6. For the application of the LNG Tariff, the coefficient of charge for reserved Regasification Capacity (ΣΔY) and the coefficient of charge for Quantity of LNG (ΣΕY) are determined for each corresponding year. 7. The coefficient of charge for reserved Regasification Capacity ΣΔΥ [in /(kwh G.C.V./day)/year] is calculated according to the following formula: ΣΔΥ = LNGCap x RR LNG / (CAP LNG x β LNG) Where: LNGCap: Regulated percentage (%), which receives a value from zero (0%) to one hundred (100%) percent and is determined with the Tariff Approval Decision at any ordinary or extraordinary Tariff Revision. RR LNG: The Required Revenue to be Recovered from the Basic Activity of LNG Facility during the corresponding year. CAP LNG: The maximum Daily Quantity of LNG regasified during the corresponding year. β LNG: Short-term contracts facilitating factor for use of the LNG Facility as defined in paragraph 10. Page 25 of 46

8. The coefficient of charge for Quantity of LNG (ΣΕY) [in /(kwh G.C.V.)] is calculated according to the following formula: ΣΕΥ = (1- LNGCap) x RR LNG / COM LNG Where: COM LNG: The annual Quantity of LNG regasified during the corresponding year. 9. For the determination of the numerical value of coefficients TRACap και LNGCap, the following are taken into consideration a) The percentage (%) of the variable Operating Expenses to the total Operating Expenses of the respective Basic Activity b) The need to provide incentives to the Transmission Users for increase of transmitted Volumes of Natural Gas in the NNGS and for the most possible effective use of it. c) The development of competition in the natural gas market. The numerical values of the above coefficients are defined with the Tariff Approval Decision at any Ordinary or Extraordinary Tariff Revision. 10. The short-term contracts facilitating factors β TRA, i, β LNG receive value equal to or lesser than the unit (1) and are defined with the Tariff Approval Decision at any Ordinary or Extraordinary Tariff Revision or with the Tariff Recalculation Decision at every yearly Tariff Recalculation, when also recalculation of short-term coefficients B take place, taking into consideration especially the following: a) The need to provide incentives to the Transmission Users for the increase of transmitted Volumes of Natural Gas in the NNGS. b) The development of competition in the natural gas market. 11. The coefficients ΣΔΜ i, ΣΕΜ i, ΣΔΥ και ΣΕΥ are determined arithmetically in the Tariff Approval Decision for the first Year of the Tariff Calculation Period at any Ordinary or Extraordinary Tariff Revision or in the Tariff Recalculation Decision for the respective year according to articles [18] and [18A]. Page 26 of 46